WO2008054880A1 - Time segmentation of frequencies in controlled source electromagnetic (csem) applications - Google Patents
Time segmentation of frequencies in controlled source electromagnetic (csem) applications Download PDFInfo
- Publication number
- WO2008054880A1 WO2008054880A1 PCT/US2007/070312 US2007070312W WO2008054880A1 WO 2008054880 A1 WO2008054880 A1 WO 2008054880A1 US 2007070312 W US2007070312 W US 2007070312W WO 2008054880 A1 WO2008054880 A1 WO 2008054880A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- time
- fundamental frequency
- subsurface formations
- frequencies
- electromagnetic energy
- Prior art date
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Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V3/00—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation
- G01V3/12—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation operating with electromagnetic waves
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V3/00—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation
- G01V3/08—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices
- G01V3/083—Controlled source electromagnetic [CSEM] surveying
Definitions
- the present invention relates to the field of hydrocarbon exploration, and more particularly to transmitting each different frequency used in controlled source electromagnetic applications within.a time windowat full power.
- Subsurface porous rocks are saturated with fluids.
- the fluids may be water (salt water or fresh water) or hydrocarbons (gas or oil).
- the resistivity of a formation may depend heavily on the fluid that is contained, within the formation. For example, formations containing hydrocarbons or fresh water tend to be much more resistive that formations that contain salt water. As a result, the resistivity of subsurface formations (c.g , porous rocks) may be measured to determine if the formation is likely to contain hydrocarbons
- CSEM controlled source electromagnetics
- CSEM typically uses a finite size transmitter in which a known time-varying current is made to flow in the subsurface formations by a suitable generator or power supply.
- the transmitter is typically coupled to two electrodes.
- The.two electrodes are electrically connected to one another via the salt water which acts as a conductor.
- a circuit is formed carrying a time-varying current generated by the transmitter.
- the time-varying circuit produces a time-varying electromagnetic field which according to Faraday's Law produces a voltage, which drives currents in the ground. That is, the time-varying electromagnetic field causes currents to flow in the subsurface formations.
- the currents in the subsurface formations may produce secondary magnetic fields which are measured by receivers placed on the ocean floor. The resistivity of the subsurface formations lying below the receivers may be inferred from the magnitude of these secondary magnetic fields.
- the transmitter generates an output current at various frequencies to detect subsurface formations at different depths and'regions of the subsurface.
- the frequency range for CSEM is typically between 1/32 Hz to 32 Hz. Different frequencies are required to detect subsurface formations at different depths and regions of the subsurface because, in general, lower frequencies are able to penetrate to greater depths and higher frequencies can provide more response at shallower depths.
- Different frequencies may penetrate .across subsurface formations in a variety of ways.
- a vessel towing the transmitter by a line may pass the subsurface formations using a single frequency (e.g., 1/3 Hz) and then make a second pass over the subsurface formations using >a ⁇ second frequency (e.g., 1 Wz).
- a single frequency e.g. 1/3 Hz
- a second frequency e.g. 1 Wz
- the transmitter may transmit a complex waveform that can be deconvolved into a number of frequencies, which are often harmonics of the waveform.
- the energy generated at any particular frequency is greatly reduced using this method.
- the signal-to-noise ratio is lower thereby making it more- difficult to accurately measure the resistivity in the subsurface formations.
- the transmitter may transmit a square wave at a fundamental frequency.
- the transmitted square wave will produce energy at the fundamental frequency and also at each odd harmonic frequency. For example, a fundamental frequency of 1 Hz will also contain energy at 3 Hz, 5 Hz and beyond.
- the energy contained within the harmonic frequencies is much reduced from the power at the fundamental frequency.
- this alternative method also has problems with having a low signal-to- noise ratio thereby making it more difficult to accurately measure the resistivity in the subsurface formations.
- the invention relates to a method for measuring a resistivity of a subsurface formation that includes transmitting continuously a signal at a first fundamental frequency at full power for a first period of time within a single window of time causing electromagnetic energy to propagate in the subsurface formations, transmitting continuously the signal at a second fundamental frequency 'at full power for a second period of time within the single window of time causing electromagnetic energy to propagate in the subsurface formations, measuring variations in the electromagnetic energy propagated through the subsurface formations at receivers at the first and the second fundamental frequencies, and determining the resistivity; of the subsurface formations using the measurements of the variations in electromagnetic energy ⁇ at the receivers.
- the invention in another aspect, relates to an electromagnetic transmitter that includes a source, a first electrode electrically connected to the source; and a second electrode electrically connected to the source.
- the source may be configured to transmit continuously a signal at a first fundamental frequency at full power for a first period of time within a single window of time causing electromagnetic energy to propagate in the, subsurface formations, and to transmit continuously the signal at a second fundamental frequency at full power for a second period of time within the single window of time causing electromagnetic energy to propagate in the subsurface formations.
- the invention in another aspect, relates to an electromagnetic survey system that includes one or more receivers positioned on a seafloor, an electromagnetic transmitter that includes a first electrode electrically connected to die source, and a second electrode electrically connected to the source.
- the source may be configured to transmit continuously a signal at a first fundamental frequency at full power for a first period of lime within a single window of lime causing electromagnetic energy to propagate in the subsurface formations, and transmit continuously the signal at a second fundamental frequency at full power for a second period of time within the single window of time causing electromagnetic energy to propagate in the subsurface formations.
- the system may also include a computer containing executable code, such that when executed, causes the computer to analyze data from the receivers to determine a characteristic of a sub-surface formation.
- Figure 1 is an example of a CSEM system for measuring the resistivity in subsurface formations
- Figure 2 is an example plot of power versus time illustrating a transmitter generating a square wave at full power at three separate fundamental frequencies during three separate time periods within a window of time;
- Figures 3A-3C are example tables illustrating example frequencies (fundamental frequencies and their associated harmonic frequencies) transmitted during each time period as well as the associated current generated for each of the frequencies;
- FIG. 4 is an example flowchart of a method for accurately and efficiently measuring the resistivity in subsurface formations using CSEM technology in accordance with an embodiment of the present invention.
- FIG. 1 illustrates a CSEM system 10 for measuring the resistivity in subsurface formations 24 in accordance with an embodiment of the present invention.
- System 10 includes a vessel 12 towing a transmitter or source 14 via a cable 16.
- System 10 includes receivers 20 positioned on the sea floor 22 above subsurface formations 24.
- formation 24b is a shale formation and formation 24a is an oil-sand.
- Transmitter 14 includes electrodes 18a, 18b. Transmitter 14 is configured to generate a time-varying current. Electrodes 18a, 18b are coupled electrically via the sea water, which acts as a conductor thereby forming a circuit carrying a time-varying current generated by transmitter 14. Transmitter 14 is configured to generate an output current at various frequencies in order to detect subsurface formations at different depths and regions of the subsurface.
- the frequency range for CSEM is typically between 1/32 Hz to 32 Hz, although other frequencies may. be used. Different frequencies arc required to detect subsurface formations 24 at different depths and regions of the subsurface because, in general, lower fiequencies are able to penetrate to greater depths and higher frequencies can provide more response at shallower depths.
- Electrodes 18 are Coupled together to form a circuit carrying a time- vary ing current.
- the time-varying current carried by the circular loop of wire produces a time-varying electromagnetic field which according to Faraday's Law produces an electromotive force or voltage, which drives currents (i.e., causes currents to flow) in the subsurface formations 24 beneath floor 22.
- the currents in the subsurface formations 24 produce secondary magnetic fields. These secondary magnetic fields are measured by receivers 20. That is, the variations in electromagnetic energy are measured by receivers 20.
- Receivers 24 may be placed on floor 22 spaced apart from one another at a given spacing.
- Each receiver 20 may be configured to include sensors located at the end of "arms" that are approximately 10 meters in length. The variations in electromagnetic energy are' measured by receivers 20 across these arms. It is noted thatother designs and configurations fore electromagnetic receivers may be used.
- Measurements of these variations in electromagnetic energy may be used by a computer 26 to determine the resistivity of subsurface formations 24.
- the data collected by receivers 20 e.g., variations in electromagnetic energy
- the computer 26 does not necessarily have to be located on vessel 12, but may be located in any location (e.g., office building) capable of receiving the data collected by receivers 20.
- Transmitter 14 must generate an output current at various frequencies in order to investigate subsurface formations 24 at different depths and regions of the subsurface
- An example CSEM method 10 provides generating an output current at various frequencies, each at full power, within a single window of time. Thus the resistivity of formation 24 at different depths can be more accurately measured, while reducing the number of passes over the formation 24.
- Figure 2 is a plot of power versus time illustrating transmitter 14 (Figure 1) generating a square wave at full power at three separate fundamental frequencies during three separate time periods within a window of time (e.g., 100 seconds).
- the window of time 28 may be an integer multiple of a period of the waveform of the generated signal (e.g., square wave).
- the transmitter 14 generates a square wave at three separate frequencies 30, 32, 34 within v single window of time 28.
- Each frequency 30, 32, 34 is generated during a respective separate time period 36, 38, 40 of time windpw 28.
- the first frequency 30 is generated during the first time period 36
- the second frequency 32 is generated during the first time period 38, etc.
- Figures 3 A, 3B and 3C ' illustrate the frequencies 30, 32, 34 (fundamental frequencies and their associated harmonic frequencies) transmitted by transmitter 14 during each respective time period 36, 38, 40 as well as the associated current (and indirectly power) generated for each of the frequencies in accordance with an embodiment of the present invention. It is noted that although Figures 3 A, 3B, and 3C show three fundamental frequencies, other numbers of fundamental frequencies may be used. For example, two or four or more fundamental frequencies may be used
- transmitter 14 generates a square wave at the first fundamental frequency 30 of 1 Hz at full power (in this example, full power corresponds to a current of 1,000 Amperes) for first time period 36 (0 to 20 seconds) in a single window of time 28 (100 seconds).
- the component frequencies of the square wave generated may be referred to as "harmonic frequencies.” These harmonic frequencies are naturally produced as a result of the generation of the current at the fundamental frequency.
- the odd harmonic frequencies e.g., 3 rd harmonic frequency represented as 3fb, 5 th harmonic frequency represented as 5fo, 7 ⁇ harmonic frequency represented as 7fo
- the odd harmonic frequencies for the first fundamental frequency 30 of 1 Hz used during the first period of time 36 correspond to 3 Hz, 5 Hz and 7 Hz for the third, fifth and seventh harmonic frequencies, respectively.
- first fundamental frequency 30 is transmitted by transmitter 14 at full power -(in this example, full power corresponds to a current of 1,000 Amperes) during the first period of time 36.
- full power corresponds to a current of 1,000 Amperes
- the current transmitted at fundamental frequency 30 (1 Hz) during first period of time 36 is at 1264 Amperes (note that transmitting a 1000 amp square wave will produce a fundamental current at 1267 amps).
- the current transmitted at the harmonic frequencies (3f 0 , 5fo and 7fo) may be less.
- the current transmitted at 3fo (3 Hz) during first period of time 36 is at 407 Amperes.
- the current transmitted at 5f ⁇ (5 Hz) during first period of time 36 is at 227 Amperes.
- the current transmitted at 7fo (7 Hz) during first period of time 36 is at 144 Amperes.
- the higher the harmonic frequency the less current that is transmitted at that frequency which results in a reduction in power (power is directly proportional to the amount of current being generated).
- transmitter 14 generates a square wave at second fundamental frequency 32 of 3 Hz at full power for second period of time 38 (20 to 55 seconds) in single window of time 28 (100 seconds).
- Figure 3C illustrates transmitter 14 generating a square wave at third fundamental frequency 34 of 5 Hz at full power for a third period of time 40 (55 to 100 seconds) in a single window of time 28 (100 seconds).
- transmitter 14 generated current at second fundamental frequency 32 of 3 Hz during second period of time 38 which is the 3 rd harmonic frequency of first fundamental frequency 30 of 1 Hz transmitted during first period of time 36.
- the total power at 3 Hz is greater than the total power of the source 14 since transmitter 14 generated current at 3 Hz as a fundamental frequency at I 1 OOO Amperes as well as the third harmonic frequency during the fust period of time at 500 Amperes.
- the amount of noise in the signal-to-noise ratio generated in the responses to the square waves at 3 Hz is reduced thereby improving the accuracy in determining the resistivity of the subsurface formations.
- transmitter 14 As transmitter 14 generates current at different frequencies, different time-varying electromagnetic fields are generated. Responses to these electromagnetic fields may result in secondary magnetic fields being produced bythe subsurface formations as a result of currents being caused to flow in the subsurface formations. The variations in electromagnetic energy as result of these secondary magnetic fields are measured- by receivers 20. Tire data collected by receivers 20 may be averaged across each time period 36, 38, 40 individually within the single window of time 28 to reduce the noise thereby increasing the signal-to-noise ratio and improving the accuracy in determining the resistivity of subsurface formations 24. For example, the data collected by receivers 20 during first period of time 36 when transmitter 14 transmits the square wave at first fundamental frequency 30 may be averaged over first period of time 36.
- the data collected by receivers 20 during second and third periods of time 38, 40 may be averaged over the second and third periods of time, respectively.
- [0034J By transmitting three different fundamental frequencies 30, 32, 34 within a single window of time 28, one is able to collect the information one would if one made three separate passes over subsurface formations 24 transmitting at a different frequency for each pass. Hence, the time inefficiency in making multiple passes over subsurface formations is avoided.
- transmitter 14 is also configured to transmit a wide range of frequencies not within the harmonics of the fundamental frequency. Further, the frequency rates and the power levels used in Figures 2 and 3 are exemplary.
- transmitter 14 continuously transmits an electromagnetic signal at a first fundamental frequency 30 (e.g., 1 Hz) and associated harmonic frequencies.
- the electromagnetic signal is a square wave.
- the signal may be transmitted at full power for first time period 36 (e.g., 0 to 20 seconds) within single window of time' 28 (e.g., 100 seconds).
- the transmitted electromagnetic energy propagates in,subsurfacc formations 24 as a result of transmitting the square wave.at the first fundamental frequency 30 and associated harmonic frequencies.
- receivers 20 measure the resulting electromagnetic signal at positions on the sea floor.
- the resulting signal may indicate the resistivity of subsurface formations 24, through which the electromagnetic signal has propagated.
- the measurement may receive resulting electromagnetic signals at the first fundamental frequency 30 and the associated harmonic frequencies.
- transmitter 14 continuously transmits an electromagnetic signal at a second fundamental frequency 32 (e.g., 3 Hz) and associated harmonic frequencies.
- the electromagnetic signal is a square wave.
- the signal may be transmitted at full power for second time period 36 (e.g., 20 to 55 seconds) within single window of time 28 (e.g., 100 seconds).
- the transmitted electromagnetic energy propagates in subsurface formations 24 as a result of transmitting the square wave at the second fundamental frequency 36 and associated harmonic frequencies.
- receivers 20 measure the resulting electromagnetic signal at positions on the sea floor.
- the resulting signal may indicate the resistivity of subsurface formations 24, through which the electromagnetic signal has propagated.
- the measurement may receive resulting electromagnetic signals at the second fundamental frequency 32 and the associated harmonic frequencies.
- step 56 computer 26 determines the resistivity of subsurface formations 24 using the electromagnetic measurements of receivers 20.
- Such computer may be located on the vessel 12, or it may be located remotely, such as in an analysis center.
- the data may be transmitted, such as by satellite or by the internet, to the remote location for analysis.
- Method 42 may include other and/or additional steps that, for clarity, are not depicted. Method 42 may further be executed in a different order presented and that the order presented in the discussion of Figure 4 is illustrative: Further, certain steps in method 40 may be executed in a substantially simultaneous manner.
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- Life Sciences & Earth Sciences (AREA)
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- Environmental & Geological Engineering (AREA)
- Geology (AREA)
- General Life Sciences & Earth Sciences (AREA)
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Abstract
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Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
MX2009004711A MX2009004711A (en) | 2006-11-02 | 2007-06-04 | Time segmentation of frequencies in controlled source electromagnetic (csem) applications. |
GB0908471A GB2456277A (en) | 2006-11-02 | 2009-05-18 | Time segmentation of frequencies in controlled source electromagnetic (csem) applications |
NO20092107A NO20092107L (en) | 2006-11-02 | 2009-05-29 | Time segmentation of frequencies in electromagnetic controlled source applications |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US11/555,935 | 2006-11-02 | ||
US11/555,935 US7667464B2 (en) | 2006-11-02 | 2006-11-02 | Time segmentation of frequencies in controlled source electromagnetic (CSEM) applications |
Publications (1)
Publication Number | Publication Date |
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WO2008054880A1 true WO2008054880A1 (en) | 2008-05-08 |
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ID=38893290
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Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2007/070312 WO2008054880A1 (en) | 2006-11-02 | 2007-06-04 | Time segmentation of frequencies in controlled source electromagnetic (csem) applications |
Country Status (5)
Country | Link |
---|---|
US (1) | US7667464B2 (en) |
GB (1) | GB2456277A (en) |
MX (1) | MX2009004711A (en) |
NO (1) | NO20092107L (en) |
WO (1) | WO2008054880A1 (en) |
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US9195783B2 (en) | 2010-08-16 | 2015-11-24 | Exxonmobil Upstream Research Company | Reducing the dimensionality of the joint inversion problem |
US9453929B2 (en) | 2011-06-02 | 2016-09-27 | Exxonmobil Upstream Research Company | Joint inversion with unknown lithology |
US9494711B2 (en) | 2011-07-21 | 2016-11-15 | Garrett M Leahy | Adaptive weighting of geophysical data types in joint inversion |
US9702995B2 (en) | 2011-06-17 | 2017-07-11 | Exxonmobil Upstream Research Company | Domain freezing in joint inversion |
US9846255B2 (en) | 2013-04-22 | 2017-12-19 | Exxonmobil Upstream Research Company | Reverse semi-airborne electromagnetic prospecting |
US10379255B2 (en) | 2010-07-27 | 2019-08-13 | Exxonmobil Upstream Research Company | Inverting geophysical data for geological parameters or lithology |
US10591638B2 (en) | 2013-03-06 | 2020-03-17 | Exxonmobil Upstream Research Company | Inversion of geophysical data on computer system having parallel processors |
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GB2455664B (en) * | 2006-09-13 | 2011-02-16 | Exxonmobil Upstream Res Co | Rapid inversion of electromagnetic reconnaissance survey data |
WO2009075961A1 (en) * | 2007-12-12 | 2009-06-18 | Exxonmobil Upstream Research Company | Method and apparatus for evaluating submarine formations |
GB2476018B (en) | 2008-09-24 | 2012-08-15 | Exxonmobil Upstream Res Co | Systems and methods for subsurface electromagnetic mapping |
MX2011009538A (en) * | 2009-03-12 | 2011-11-18 | Advanced Hydrocarbon Mapping As | Method and apparatus for offshore hydrocarbon electromagnetic prospecting based on circulation of magnetic field derivative measurements. |
NO330702B1 (en) * | 2009-03-20 | 2011-06-14 | Advanced Hydrocarbon Mapping As | Method and apparatus for electromagnetic mapping of subsea hydrocarbon deposits based on total magnetic field paints |
WO2011115921A2 (en) * | 2010-03-19 | 2011-09-22 | Schlumberger Canada Limited | Uncertainty estimation for large-scale nonlinear inverse problems using geometric sampling and covariance-free model compression |
US20120194196A1 (en) * | 2011-02-02 | 2012-08-02 | Leendert Combee | Electromagnetic Source to Produce Multiple Electromagnetic Components |
US20140058677A1 (en) * | 2012-08-23 | 2014-02-27 | Westerngeco, L.L.C. | Method for processing electromagnetic data |
WO2014035543A1 (en) | 2012-08-30 | 2014-03-06 | Exxonmobil Upstream Research Company | Processing methods for time division csem data |
EP3004946A2 (en) | 2013-06-03 | 2016-04-13 | Exxonmobil Upstream Research Company | Uncertainty estimation of subsurface resistivity solutions |
US9562988B2 (en) | 2013-12-13 | 2017-02-07 | Halliburton Energy Services, Inc. | Methods and systems of electromagnetic interferometry for downhole environments |
WO2016085509A1 (en) * | 2014-11-26 | 2016-06-02 | Halliburton Energy Services, Inc. | Offshore electromagnetic reservoir monitoring |
WO2016085511A1 (en) | 2014-11-26 | 2016-06-02 | Halliburton Energy Services, Inc. | Onshore electromagnetic reservoir monitoring |
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Cited By (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10379255B2 (en) | 2010-07-27 | 2019-08-13 | Exxonmobil Upstream Research Company | Inverting geophysical data for geological parameters or lithology |
US9195783B2 (en) | 2010-08-16 | 2015-11-24 | Exxonmobil Upstream Research Company | Reducing the dimensionality of the joint inversion problem |
US9453929B2 (en) | 2011-06-02 | 2016-09-27 | Exxonmobil Upstream Research Company | Joint inversion with unknown lithology |
US9702995B2 (en) | 2011-06-17 | 2017-07-11 | Exxonmobil Upstream Research Company | Domain freezing in joint inversion |
US9494711B2 (en) | 2011-07-21 | 2016-11-15 | Garrett M Leahy | Adaptive weighting of geophysical data types in joint inversion |
US10591638B2 (en) | 2013-03-06 | 2020-03-17 | Exxonmobil Upstream Research Company | Inversion of geophysical data on computer system having parallel processors |
US9846255B2 (en) | 2013-04-22 | 2017-12-19 | Exxonmobil Upstream Research Company | Reverse semi-airborne electromagnetic prospecting |
Also Published As
Publication number | Publication date |
---|---|
MX2009004711A (en) | 2009-09-07 |
GB0908471D0 (en) | 2009-06-24 |
GB2456277A (en) | 2009-07-15 |
US20080106265A1 (en) | 2008-05-08 |
NO20092107L (en) | 2009-07-31 |
US7667464B2 (en) | 2010-02-23 |
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